Methods and systems for real-time monitoring and processing of wellbore data

ABSTRACT

Apparatus and methods for monitoring and processing wellbore data are disclosed. An integrated digital ecosystem comprises an applied fluid optimization specialist and one or more sensors communicatively coupled to the applied fluid optimization specialist. The applied fluid optimization specialist receives data relating to performance of subterranean operations from the one or more sensors and interprets the data received. The applied fluid optimization specialist then regulates the performance of subterranean operations based on the interpretation of the data received.

BACKGROUND

The present invention relates to subterranean operations and, moreparticularly, to apparatus and methods for monitoring and processingwellbore data.

Performance of subterranean operations entails various steps, each usinga number of devices. For instance, one of the steps in performingsubterranean operations is the performance of drilling operations.

Drilling operations play an important role when developing oil, gas orwater wells or when mining for minerals and the like. During thedrilling operations, a drill bit passes through various layers of earthstrata as it descends to a desired depth. Drilling fluids are commonlyemployed during the drilling operations and perform several importantfunctions including, but not limited to, removing the cuttings from thewell to the surface, controlling formation pressures, sealing permeableformations, minimizing formation damage, and cooling and lubricating thedrill bit. Similarly, completion fluids may be used when performingsubterranean operations.

It is important to monitor the performance of subterranean operations toensure they satisfy job requirements and meet safety standards. Forinstance, a mud engineer at the rig site may perform a number of testseach day. These tests are well known to those of ordinary skill in theart and will therefore not be discussed in detail herein. The mudengineer may report results of tests that are performed several timesper day in a single mud report reflecting the status of operations.Additionally, various sensors may provide pieces of data regardingdifferent aspects of the operations being performed. However, theinformation obtained from various components is currently not integratedinto a central intelligent system which is capable of processing theinformation received and optimizing system performance. Therefore,current methods and systems fail to optimize the overall systemperformance in real-time.

For instance, the mud engineer typically sends the mud report to atechnical professional in an office which may be remotely located. Thetechnical professional and the mud engineer will then analyze the reportin order to address any problems reflected therein. Typically, the mudreport provides information regarding the properties of the drillingfluid at the surface. That information may then be used to model thesubterranean operation. However, by the time a problem is identified,the mud report may already be several hours old. As a result, the mudreport and the corresponding data generated regarding the subterraneanoperation using that report may not be indicative of the operations atthe exact point in time. Moreover, the delay in identification andremedy of any potential problems adversely impacts the performance ofthe subterranean operations.

SUMMARY

The present invention relates to subterranean operations and, moreparticularly, to apparatus and methods for monitoring and processingwellbore data.

In one embodiment, the present disclosure is directed to an integrateddigital ecosystem comprising: an applied fluid optimization specialist;one or more sensors communicatively coupled to the applied fluidoptimization specialist; wherein the applied fluid optimizationspecialist receives data relating to performance of subterraneanoperations from the one or more sensors; wherein the applied fluidoptimization specialist interprets the data received from the one ormore sensors; and wherein the applied fluid optimization specialistregulates the performance of subterranean operations based on theinterpretation of the data received.

In another embodiment, the present disclosure is directed to a method ofoptimizing performance of subterranean operations comprising monitoringperformance of a subterranean operation; determining whether thesubterranean operation is being performed at an optimal level;identifying one or more causes for the subterranean operation not beingperformed at an optimal level; and generating an intervention if thesubterranean operation is not being performed at an optimal level,wherein level of intervention depends on the one or more causes for thesubterranean operation not being performed at an optimal level.

In yet another embodiment, the present invention is directed to a methodof optimizing performance of a subterranean operation comprising:

providing one or more sensors; wherein the one or more sensors gatherdata relating to performance of the subterranean operation; monitoringdata gathered by the one or more sensors to identify one or moreoperational conditions; identifying need for an intervention based onthe one or more identified operational conditions; determining anintervention level based on the gathered data; generating anintervention corresponding to the determined intervention level; andresponding to the intervention based on the intervention level.

The features and advantages of the present invention will be apparent tothose skilled in the art from the description of the preferredembodiments which follows when taken in conjunction with theaccompanying drawings. While numerous changes may be made by thoseskilled in the art, such changes are within the spirit of the invention.

BRIEF DESCRIPTION OF THE DRAWINGS

These drawings illustrate certain aspects of some of the embodiments ofthe present invention, and should not be used to limit or define theinvention.

FIG. 1 depicts general method steps in accordance with an exemplaryembodiment of the present disclosure.

FIG. 2 depicts an Integrated Digital Ecosystem (“IDE”) in accordancewith an exemplary embodiment of the present disclosure for performingthe method steps of FIG. 1.

FIG. 3 depicts an exemplary AFO intervention workflow in accordance withan embodiment of the present disclosure.

FIG. 4 depicts an AFO service for monitoring drilling operationsworkflow in accordance with an exemplary embodiment of the presentdisclosure.

FIG. 5 depicts an AFO service for monitoring hole cleaning workflow inaccordance with an exemplary embodiment of the present disclosure.

FIG. 6 depicts an AFO service for monitoring excessive Surge/Swabpressures in accordance with an exemplary embodiment of the presentdisclosure.

FIG. 7 depicts an AFO service for monitoring influx in accordance withan exemplary embodiment of the present disclosure.

FIG. 8 depicts an AFO service for monitoring Pack-Off in accordance withan exemplary embodiment of the present disclosure.

FIG. 9 depicts an AFO service for monitoring wellbore breathing inaccordance with an exemplary embodiment of the present disclosure.

FIG. 10 depicts an AFO service for monitoring hole enlargement inaccordance with an exemplary embodiment of the present disclosure.

FIG. 11 depicts an AFO service for monitoring lost returns in accordancewith an exemplary embodiment of the present disclosure.

While embodiments of this disclosure have been depicted and describedand are defined by reference to example embodiments of the disclosure,such references do not imply a limitation on the disclosure, and no suchlimitation is to be inferred. The subject matter disclosed is capable ofconsiderable modification, alteration, and equivalents in form andfunction, as will occur to those skilled in the pertinent art and havingthe benefit of this disclosure. The depicted and described embodimentsof this disclosure are examples only, and not exhaustive of the scope ofthe disclosure.

DETAILED DESCRIPTION

Illustrative embodiments of the present invention are described indetail herein. In the interest of clarity, not all features of an actualimplementation may be described in this specification. It will of coursebe appreciated that in the development of any such actual embodiment,numerous implementation-specific decisions may be made to achieve thespecific implementation goals, which may vary from one implementation toanother. Moreover, it will be appreciated that such a development effortmight be complex and time-consuming, but would nevertheless be a routineundertaking for those of ordinary skill in the art having the benefit ofthe present disclosure.

For purposes of this disclosure, an information handling system mayinclude any instrumentality or aggregate of instrumentalities operableto compute, classify, process, transmit, receive, retrieve, originate,switch, store, display, manifest, detect, record, reproduce, handle, orutilize any form of information, intelligence, or data for business,scientific, control, or other purposes. For example, an informationhandling system may be a personal computer, a network storage device, orany other suitable device and may vary in size, shape, performance,functionality, and price. The information handling system may includerandom access memory (RAM), one or more processing resources such as acentral processing unit (CPU) or hardware or software control logic,ROM, and/or other types of nonvolatile memory. Additional components ofthe information handling system may include one or more disk drives, oneor more network ports for communication with external devices as well asvarious input and output (I/O) devices, such as a keyboard, a mouse, anda video display. The information handling system may also include one ormore buses operable to transmit communications between the varioushardware components.

For the purposes of this disclosure, computer-readable media may includeany instrumentality or aggregation of instrumentalities that may retaindata and/or instructions for a period of time. Computer-readable mediamay include, for example, without limitation, storage media such as adirect access storage device (e.g., a hard disk drive or floppy diskdrive), a sequential access storage device (e.g., a tape disk drive),compact disk, CD-ROM, DVD, RAM, ROM, electrically erasable programmableread-only memory (EEPROM), and/or flash memory; as well ascommunications media such wires, optical fibers, microwaves, radiowaves, and other electromagnetic and/or optical carriers; and/or anycombination of the foregoing.

The terms “couple” or “couples,” as used herein are intended to meaneither an indirect or a direct connection. Thus, if a first devicecouples to a second device, that connection may be through a directconnection, or through an indirect electrical connection via otherdevices and connections. The term “communicatively coupled” as usedherein is intended to mean coupling of components in a way to permitcommunication of information therebetween. Two components may becommunicatively coupled through a wired or wireless communicationnetwork. Operation and use of such wired and wireless communicationnetworks is well known to those of ordinary skill in the art and will,therefore, not be discussed in detail herein. The term “upstream” asused herein means along a flow path towards the source of the flow, andthe term “downstream” as used herein means along a flow path away fromthe source of the flow. The term “uphole” as used herein means along thedrillstring or the hole from the distal end towards the surface, and“downhole” as used herein means along the drillstring or the hole fromthe surface towards the distal end.

It will be understood that the term “oil well drilling equipment” or“oil well drilling system” is not intended to limit the use of theequipment and processes described with those terms to drilling an oilwell. The terms also encompass drilling natural gas wells or hydrocarbonwells in general. Further, such wells can be used for production,monitoring, or injection in relation to the recovery of hydrocarbons orother materials from the subsurface. This could also include geothermalwells intended to provide a source of heat energy instead ofhydrocarbons.

The present invention relates to subterranean operations and, moreparticularly, to apparatus and methods for monitoring and processingwellbore data.

Turning now to FIG. 1, general method steps in accordance with anexemplary embodiment of the present disclosure are denoted withreference numeral 100. First, at step 102, the data generated inreal-time by the different components involved in performance ofsubterranean operations is obtained. This data may be obtained manuallyor automatically using one or more sensors. Next, at step 104, theobtained data is interpreted. In certain embodiments, one or moremathematical models may use the obtained data and generate a set ofsimulated data that can be compared with the actual data. Once the datais interpreted, at step 106, one or more aspects of the subterraneanoperations may be modified in view of that interpretation in order tooptimize overall system performance, meet safety guidelines, orotherwise comply with preset operator preferences. In certainembodiments, a comparison of the simulated data and the actual data maybe used to optimize the operational performance of the system.

FIG. 2 depicts an Integrated Digital Ecosystem (“IDE”) in accordancewith an exemplary embodiment of the present disclosure for performingthe method steps of FIG. 1, denoted generally with reference numeral200. In certain embodiments, the IDE 200 may perform the stepsidentified with reference to FIG. 1 as discussed in more detail below.

Specifically, the IDE 200 may include an Applied Fluid Optimization(“AFO”) specialist 202 which may act as a central unit for receivingdata relating to subterranean operations, interpreting that data, andmodifying the performance of the subterranean operations in response.The AFO specialist 202 may intercept a range of useful data relating tothe performance of subterranean operations in real-time from the rigsite 210. The “useful data” may include, but is not limited to, one ormore of the hole depth, the bit depth, the block position, the hookload,the True Vertical Depth (“TVD”), time/date activity, the temperature,density and/or flow of fluid(s) directed into one or more componentsperforming the subterranean operations, density and/or flow of fluid(s)flowing out of one or more components performing the subterraneanoperations, the Riser flow in, the stand pipe pressure, the rotaryRotations Per Minute (“RPM”), torque, choke pressure, bottom holetemperature (“BHT”), rate of penetration (“ROP”), the running speed,Pressure While Drilling (“PWD”) Equivalent Mud Weight (“EMW”), pitvolumes, and pit volume change. As would be appreciated by those ofordinary skill in the art, with the benefit of this disclosure, theuseful data provides the AFO specialist 202 with a snapshot of theongoing subterranean operations in real-time.

In certain embodiments, the mud engineer 204, the technical professional206 and/or the client team 208 may have access to the AFO specialist 202through a wired or wireless network. Additionally, the AFO specialist202 may provide an interface for communication of data and instructionsbetween the mud engineer 204, the technical professional 206 and theclient team 208, allowing collaboration therebetween when performing thesubterranean operations. Further, in certain embodiments, the IDE 200may provide a direct communication line between the mud engineer 204 andthe technical professional 206 in order to permit transfer of data andinstructions therebetween, bypassing the AFO specialist 202.

In certain embodiments, the AFO specialist 202 may also becommunicatively coupled to the AFO Modeling and Planner (“MaP”) 212. TheAFO MaP 212 is an AFO subsystem which is responsible for developing anexecution plan prior to performance of subterranean operations.Accordingly, the AFO MaP 212 may plan the well in advance of the actualexecution of the drilling operations. Specifically, this AFO specialistmay complete an in depth hydraulics modeling of the fluid, along withgeomechanical analysis and planning of lost circulation correctiveactions. In certain embodiments, the AFO MaP 212 may interface with theexecution AFO specialist 202 by communicating the prepared plans to theAFO specialist 202 and/or using the information gathered by the AFOspecialist 202 during the planning stage.

Additionally, the AFO specialist 202 may be communicatively coupled to anumber of components used in performance of the subterranean operationsto permit communication of real-time data relating to the subterraneanoperations to the AFO specialist 202. In certain embodiments, the AFOspecialist 202 may monitor an inventory control system 214. The trackingof the inventory control system 214 may be based on a real-time trackingof one or more desired materials such as, for example, chemicalinventory. The tracking of the chemical inventory may entail using loadsensors to monitor the amount of chemicals used, the rate of use ofchemicals, etc. In one embodiment, the inventory control system mayinform the AFO specialist 202 if the amount of one or more chemicalsfalls below a threshold value and needs to be replenished.

In certain embodiments, during drilling operations, the drilling fluidmay return cuttings from the subterranean formation to the surface.These cuttings may be analyzed and the cuttings' characterization may beused to learn about the characteristics of the formation being drilled.In one embodiment, information relating to the cuttings'characterization may be communicated from the rig site 210 to the AFOspecialist 202. Specifically, using sensor technology at the rig site210 based on particle size distribution (“PSD”) of the cuttings, densityof the cuttings, visual characteristics of the cuttings captured by acamera and/or other parameters, the cuttings from the drilling operationmay be evaluated and entered into a decision making matrix program orAFO specialist 202 workflow to determine if further fluid treatments arerequired. Similarly, in cuttings reinjection operations, the cuttingsmay be characterized and the slurries evaluated using automated densityand viscosity measurements.

Similarly, other information relating to drilling performance and fluidperformance may be communicated to the AFO specialist 202. Additionally,information relating to waste tracking and the performance of the dosingsystem may be communicated to the AFO specialist 202 from the rig site210. Accordingly, the AFO specialist 202 may control and/or monitorfluid waste for optimization of waste capacity and/or an automateddosing system for the addition of chemicals into the drilling orcompletion fluid. Moreover, in certain embodiments, the density and/orviscosity of cuttings from reinjection wells may be measured andcommunicated to the AFO specialist 202 from the rig site 210. In certainembodiments, the dosing system may be controlled by the AFO specialist202 to facilitate addition of chemicals to a drilling or completionfluid when data received by the AFO specialist 202 shows that theconcentration of the particular chemical has fallen below an optimalthreshold value.

In addition to the data generated from the general drilling operations,the AFO specialist 202 will also receive data from automated equipmentthat measure drilling fluid properties. Such automated equipmentmeasurements may include, but are not limited to, measurements relatingto density, viscosity, Particle Size Distribution (“PSD”), oil/waterratio, electrical stability, percentage of solid content, Chlorideconcentration, Cation concentration, and pH. In one embodiment, the AFOspecialist 202 may be an information handling system or may becommunicatively coupled to an information handling system to facilitateprocessing and/or storing the data received as well as issuing commandsto regulate the performance of the subterranean operations. Theinformation handling system may include computer readable instructions(referred to herein as a “software application”) that enable it to storethe generated useful data, interpret the useful data, and act on theuseful data as noted in FIG. 1. The information handling system may alsoinclude computer-readable media.

Specifically, the useful data received by the AFO specialist 202 may bedirected to the information handling system which will utilize presetparameters to determine if an issue in the operation is about to occur.For instance, in certain embodiments, preset parameters may relate tocertain sensor readings. Specifically, the AFO specialist 202 may bedesigned to identify an upcoming issue with the ongoing operations ifreadings of certain sensors fall below or raise above a predeterminedthreshold value.

Turning now to FIG. 3, the general AFO workflow intervention method inaccordance with an exemplary embodiment of the present disclosure isdenoted with reference numeral 300. The AFO specialist 202 may utilizethis workflow method to optimize overall system performance whenperforming different operations in conjunction with performance ofsubterranean operations. Generally, the AFO workflow intervention methodmay generate different levels of intervention depending on the type ofsystem failure identified by the system components. In one embodiment,the AFO specialist 202 may generate three different interventions thatmay be denoted as green intervention, yellow intervention, and redintervention, respectively, depending on the level of importance and therequired response. A green intervention may denote a low levelintervention and may be a normal communication to verify sensor values,operations, or clarify report entries and may probe the system tocontinue to monitor the condition that raised the intervention. A yellowintervention may denote a medium level intervention and may beindicative of a condition that could lead to a significant event. Forinstance, the condition giving rise to the yellow intervention may beone that can potentially become a management system hazard or anoperational hazard. When a yellow intervention is generated, the systemmay further compile a list of mitigation options to resolve thecondition. Moreover, in certain embodiments, the system may notify theoperator of the condition that gave rise to the yellow intervention andmay also contact the rig to discuss mitigation options. Once a yellowintervention is generated, the system may continue to monitor theparticular condition that gave rise to the intervention for potentialescalation to red intervention. Examples of conditions giving rise to ayellow intervention may include, but are not limited to, Surge/Swabapproaching preset limits, elevated predicted cuttings loading, orelevated predicted Equivalent Circulating Density (“ECD”).

Finally, a red intervention may denote a high level intervention and maybe indicative of a significant adverse event. As a result, once a redintervention is generated the rig may be contacted immediately todiscuss mitigation options and the operator may also be informed. Thesystem will then continue to monitor the condition giving rise to thered intervention while the problem is being resolved or mitigated.Examples of conditions giving rise to a red intervention may include,but are not limited to, gas influx, Pack-Off, lost returns, or instanceswhen Surge/Swab exceeds preset limits.

As shown in FIG. 3, the AFO intervention workflow process starts at step302 and subterranean operation of interest (i.e. “the job”) is monitoredat step 304. As discussed in more detail below, once the AFO determinesthat the particular subterranean operation is not being performed at theoptimal level, it may identify one or more issues that are preventingoptimal performance. The AFO may then generate an intervention tocorrect or mitigate issues that are adversely affecting the performanceof the subterranean operation. Variations in data are observed at step306 and at step 308, it is verified that the software application usedto generate information based on rig data is working properly. Next, atstep 310, the data obtained from the software application is verifiedwith data from the rig. Next, at step 312, it is determined whether thedata obtained is correct based on a comparison with the rig data. If thedata obtained is not correct, a green intervention is documented at step314 and the process returns to step 304. In contrast, if it isdetermined at step 312 that the data is correct, the process proceeds tostep 316 where the data is compared to workflows. Next, at step 318 itis determined whether the data indicates a significant event. If nosignificant event is detected a green intervention is documented at step314 and the process returns to step 304. If a significant event isdetected at step 318, the process proceeds to step 320 to determinewhether the significant event is one that is likely to cause immediatethreat. If the event is one that is not likely to cause an immediatethreat, a yellow intervention is documented at step 322 and the processreturns to step 304 and is repeated. As discussed above, in conjunctionwith documenting a yellow intervention, the system may communicate thethreat to a designated Point of Contact (“PoC”) and the system maycontinue to monitor the condition that gave rise to the intervention todetermine if a red intervention is needed. The PoC may be any entitydesignated as such by the system. If at step 320 it is determined thatthe significant event is one that is likely to cause immediate threat,the process may proceed to step 324 and a red intervention may bedocumented. As discussed above, upon documenting a red intervention, thesystem may communicate the threat and mitigation recommendations to adesignated PoC and continue to monitor the condition while the problemis being resolved or mitigated.

Accordingly, the AFO specialist 202 may identify a number of conditionsthat may be of interest to an operator. For instance, the AFO specialist202 may identify poor hole cleaning, a Pack Off situation, fracturingthe wellbore or drilling fluid loss to the formation. Once an issue isidentified by the AFO specialist 202, the AFO specialist 202 maycommunicate the identified issue to the mud engineer 204, the technicalprofessional 206, and/or the client team 208. In certain embodiments,the AFO specialist 202 may keep track of the different issues that comeup during the performance of the subterranean operations in acomputer-readable media. The information stored in the computer-readablemedia may be used to keep track of the different issues that have comeup during the performance of subterranean operations in real-time. Aswould be appreciated by those of ordinary skill in the art, with thebenefit of this disclosure, each of the issues identified by the AFOspecialist 202 requires a specific response from the operator inresponse to documentation of an intervention level. A few exemplaryissues that may come up when performing subterranean operations and thatmay be resolved by the AFO specialist 202 will now be discussed inconjunction with FIGS. 4-11. Specifically, FIGS. 4-11 disclose exemplarysubsystem operations that may benefit from the AFO intervention workflowof FIG. 3. However, as would be appreciated by those of ordinary skillin the art, the application of the methods and systems disclosed hereinis not limited to these specific examples. Specifically, as would beappreciated by those of ordinary skill in the art, with the benefit ofthis disclosure, the same methods and systems may be applicable to otheraspects of performance of subterranean operations without departing fromthe scope of the present disclosure.

Turning now to FIG. 4, an AFO service monitoring drilling operationsworkflow in accordance with an exemplary embodiment of the presentdisclosure is denoted generally with reference numeral 400. The AFOservice monitoring is initiated by the AFO specialist at step 402. Next,at step 404, the drilling fluid properties are monitored. The AFOspecialist is responsible for monitoring the drilling fluid propertiesand consults with the Real-Time Operations Center (“RTOC”) and theTechnical Professional. The drilling fluid properties may be used by theAFO specialist to predict characteristics of the subterranean formation.In one embodiment, the AFO specialist may utilize a software applicationand an information handling system to predict such characteristics. Theuse of information handling systems and software applications to predictsubterranean formation characteristics based on drilling fluidproperties is well known to those of ordinary skill in the art and willtherefore not be discussed in detail herein. The predictedcharacteristics may include, but are not limited to, downhole pressures,mud weight, and DrillAhead™ hydraulics (“DAH”). At step 406, the AFOspecialist determines whether the values obtained at step 404 suggestany problems or issues with the ongoing subterranean operations. Incertain embodiments, this determination may be based on whether theobtained value is below or exceeds a preset threshold value. If so, theAFO specialist links to the management system process maps for AFOissues at step 408 and reports the problem. The management system willthen take appropriate actions and generate the appropriate interventionusing the AFO intervention workflow to handle the issues identified andthe process returns to step 402 and is repeated. If no issues areidentified at step 406, the process proceeds to step 410 where the AFOspecialist is responsible for monitoring actual data from the well siteand consults with the RTOC and the technical professional in theprocess. This actual data may include, but is not limited to, the flowin, the standpipe pressure, the unit of gas, rate of penetration(“ROP”), and/or Torque. The process then proceeds to step 412 todetermine whether the obtained values suggest any problems with theperformance of the subterranean operations. In certain embodiments, thisdetermination may be based on whether the obtained value is below orexceeds a preset threshold value. If any issues are identified, the AFOspecialist may report the problem to the management system at step 408and the process proceeds to step 402. If no problems are noted, theprocess may proceed to step 414.

At step 414, the AFO specialist may be responsible for monitoring thepressure while drilling (“PWD”) and may consult with the RTOC and thetechnical professional in the process. The data monitored by the AFOspecialist may include, but is not limited to pressure values,equivalent mudweight (“EMW”) values and/or the surge/swab values.

At step 416, the AFO specialist determines whether the values obtainedat step 414 suggest any problems or issues with the ongoing subterraneanoperations. In certain embodiments, this determination may be based onwhether the obtained value is below or exceeds a preset threshold value.If so, the AFO specialist links to the management system at step 408 andreports the problem. The management system will then take appropriateactions and generate the appropriate intervention using the AFOintervention workflow to handle the issues identified and the processrepeats to step 402.

Turning now to FIG. 5, an AFO service monitoring hole cleaningoperations in accordance with another exemplary embodiment of thepresent disclosure is denoted generally with numeral 500. This processmap defines AFO services concerning hole cleaning issues. The holecleaning process starts at step 502. Next at step 504, the AFOspecialist monitors the real-time data from the rig regarding cuttingsload and consults with the RTOC and the Technical Professional.Specifically, at step 504, the AFO specialist may confirm that data istransmitted and received correctly. For instance, the AFO specialist mayrun an instance of DAH while changing parameters known to affect holecleaning such as pump rate, ROP, RPM, and circulation time. The AFOspecialist may then communicate information based upon this analysis.Next, at step 506, the AFO specialist may monitor Equivalent CirculationDensity (“ECD”). Specifically, the ECD typically drops drastically afterconnection and climbs continually while drilling. The AFO specialist mayverify that the real-time data is tracking residual cuttings when thebit is off the bottom of the wellbore. The AFO specialist may alsoobserve the residual cuttings column. Next, at step 508, the AFOspecialist may check the real-time data from the drilling activity andverify whether that data is correct.

Specifically, the cuttings load may be lower than expected when the rigis sliding. In such instances, the real-time data relating to drillingactivity may be incorrect and may display information indicating arotating drilling operation when the rig is actually sliding. If thathappens, the AFO specialist may run the RPM calculator to correct theissue. Finally, at step 510 a consistently high ECD value is compared toPWD to verify that the inputs of the information handling systemgenerating the real-time data are correct. Additionally, at step 510,the AFO specialist will verify that the data generated by the wellsiteapplication software is correct. Finally, the AFO specialist may observethe units of wellbore gas and may analyze the formation being drilledand adjust the cuttings' Specific Gravity (“SG”) if necessary. If at anypoint during the process set forth in FIG. 5 the AFO specialistidentifies an issue that may give rise to potential or immediatethreats, the process may be directed to the AFO intervention workflow ofFIG. 3 and an appropriate intervention signal may be documented.

Turning now to FIG. 6, an AFO service for monitoring excessiveSurge/Swab pressures is denoted generally with reference numeral 600.Specifically, during drilling process, as the drillstring moves downthrough the wellbore it may create a pressure which is typicallyreferred to as a “Surge.” In contrast, when the drillstring is beingpulled out of the wellbore it may create a vacuum which is typicallyreferred to as a “Swab.” Accordingly, when performing subterraneanoperations, it is desirable to ensure that the Surge and Swab createddue to movement of the drillstring does not exceed the formation limits.In accordance with an exemplary embodiment of the present disclosure,the process starts at step 602. Next, at step 604, the crossing surgeand/or swab limits are defined by the operator. The operator may consultwith the Technical Professional, the RTOC and/or the AFO specialist whendefining these limits. At step 606, the AFO specialist runs the trippingschedule and determines maximum speed for surge (trip in) and the swab(trip out). The AFO specialist then observes EMWs to ensure they arewithin a safe window as determined by leak-off and pore pressure. Next,at step 608, if the EMWs exceed limits established by the operator, theAFO specialist may recommend a running speed for the drillstring toresolve the issue. The AFO specialist may consult with the RTOC and/orthe Technical Professional at steps 606 and/or 608. The process thenterminates at step 610. If at any point during the process set forth inFIG. 6 the AFO specialist identifies an issue that may give rise topotential or immediate threats, the process may be directed to theintervention workflow of FIG. 3 and an appropriate intervention signalmay be documented.

Turning now to FIG. 7, an AFO service for monitoring influx is denotedgenerally with reference numeral 700. Specifically, influx refers toflow of fluids and/or gasses from the formation into the wellbore. Inaccordance with an embodiment of the present disclosure, an influxworkflow is initiated at step 702 by the AFO specialist. Next, at step704 the AFO specialist determines if there is a formation liquid influx.Specifically, a formation liquid influx may be detected if the PWD EMWdecreases while the calculated pressure using real-time data from therig remains almost constant. Specifically, PWD equipment measure actualpressures at the wellbore. A low rate of influx may cause a gradualdecrease in EMW while a high rate of influx may cause a rapid decreasein EMW. At the same time, an information handling system may be used tocalculate the pressure using rig data. The two pressures may be comparedto detect an influx. In instances where the formation liquid contains alarge amount of solids, the drop in the PWD EMW may not be easilydetected. In certain embodiments, the AFO specialist may characterizethe formation liquid influx when a continued, sustained flow is detectedafter the pumps are turned off. Next, at step 706 it is determinedwhether there is a formation liquid influx. If there is no formationliquid influx, the process continues to step 708 to determine if thereis a formation gas influx and at step 710 a decision is made. If noformation gas influx is detected, the process returns to step 704.

If a formation liquid influx or a formation gas influx is detected, theprocess continues to step 712 to handle the fluid influx. In certainembodiments, once the influx is detected, the AFO specialist may consultwith the RTOC and the Technical Professional at step 712. The propercontacts may then be notified and the data from the wellbore may beanalyzed to identify possible causes of the influx. Next, at step 714,the wellbore may be monitored for continued impact of the influx andprocess returns to step 704. In certain embodiments, once in step 712the AFO specialist identifies an influx, the process may be directed tothe intervention workflow of FIG. 3 and an appropriate interventionsignal may be documented.

Turning now to FIG. 8, an AFO service for monitoring Pack-Off is denotedgenerally with reference numeral 800. Specifically, Pack-Off refers to aclosing of the annular wellbore space due to a formation collapse or arestriction of the annular wellbore space by cuttings that are removedto the surface when performing drilling operations. The process isinitiated at step 802 and the AFO specialist may detect a Pack-Off atstep 804. The AFO specialist may consult with the RTOC and the TechnicalProfessional in this step. Typically, a Pack-Off event may be detectedat step 804 when there is a sudden loss of the ability to circulatefluids through the wellbore annulus. The Pack-Off may also lead to highpump pressures and/or an increase in PWD ECDs. If a Pack-Off isdetected, the AFO specialist may handle this condition at step 806. Incertain embodiments, once in step 804 the AFO specialist identifies aPack-Off condition, the process may be directed to the interventionworkflow of FIG. 3 and an appropriate intervention signal may bedocumented. The process then returns to step 804 where the AFOspecialist continues to monitor the subterranean operations to detectanother potential Pack-Off condition.

Turning now to FIG. 9, an AFO service for monitoring wellbore breathingis denoted generally with reference numeral 900. When performingsubterranean operations, additional dynamic pressures in the wellboremay initiate formation fractures which may take on the drilling fluid.For instance, the circulation of the drilling fluid through the wellboremay create such additional fractures. Consequently, fluids may seep intothese additional fractures. Wellbore breathing refers to a conditionwhere once the pumps used in performing subterranean operations areturned off, the fluids that have seeped into these additional fracturesleak back into the wellbore. Specifically, once the pumps are turned offand the pressure in the wellbore is reduced and these additionalfractures close, the drilling fluid is displaced and causes a surfaceflow. The AFO service process is initiated at step 902, and at step 904the AFO specialist with consultation from the RTOC and/or the TechnicalProfessional may detect a wellbore breathing condition. A wellborebreathing condition may be detected if there is a flow back once thepumps are turned off and/or there is a pit gain above normal levels oncethe pumps are turned off. Moreover, when wellbore breathing occurs, therecorded PWD data may show a “rounded” pumps-off signature rather than a“square” one. Once a wellbore breathing situation is detected at step904, the process continues to step 906 where the AFO specialist handlesthis condition. In certain embodiments, the process may be directed tothe intervention workflow of FIG. 3 and an appropriate interventionsignal may be documented once a wellbore breathing condition isidentified at step 904. Once the wellbore breathing condition has beenhandled at step 906, the process then returns to step 904 where the AFOspecialist continues to monitor the subterranean operations to detectanother potential wellbore breathing condition.

Turning now to FIG. 10, an AFO service for monitoring hole enlargementis denoted generally with reference numeral 1000. Generally, holeenlargement or “washout” refers to an enlarged region of a wellbore. Awashout is an openhole section of the wellbore which may be larger thanthe original hole size or size of the drill bit. Washout may be causedby a number of factors including, but not limited to, excessive bit jetvelocity, soft or unconsolidated formation, in-situ rock stresses,mechanical damage by BHA components, chemical attack and swelling orweakening of shale as it contacts fresh water. In accordance with anembodiment of the present disclosure, the AFO specialist begins the AFOservice for monitoring hole enlargement at step 1002 and continuesmonitoring to detect a hole enlargement condition at step 1004. Theoccurrence of a hole enlargement condition may be characterized by (1)PWD ECDs that due to frictional losses are lower than those calculatedusing real-time data from the rig; (2) Stand Pipe Pressure (“SPP”) thatis lower than the total system pressure calculated using real-time datafrom the rig; and/or (3) when caused by sloughing shale, a higher thanexpected cuttings load. Once a hole enlargement condition is detected atstep 1004, the process may proceed to step 1006 to characterize thecondition. Specifically, the AFO specialist may consult with the RTOCand/or the Technical Professional and may obtain a simulation of thesubterranean operations using a slightly overgauge hole and compare theresults with the actual PWD data to characterize the hole enlargement.In certain embodiments, the AFO specialist may have a logger or mudengineer physically log the hole by pumping an indicator downhole anddetermining how long it takes the indicator to return to the surface.The time it takes the indicator to return to the surface together withinformation regarding the pump efficiency may be used to calculate thehole volume and identify an enlarged hole. In certain embodiments, oncein step 1008 the AFO specialist identifies a hole enlargement or oncethe hole enlargement is characterized in step 1006, the process may bedirected to the intervention workflow of FIG. 3 and an appropriateintervention signal may be documented. The process then returns to step1004 where the AFO specialist continues to monitor the subterraneanoperations to detect another potential wellbore enlargement condition.

Turning now to FIG. 11, an AFO service for monitoring lost returns isdenoted generally with reference numeral 1100. Generally, lost returnsrefers to a condition where the formation cannot withstand the wellborepressure and hydrocarbons being produced from a subterranean formationare forced into the formation instead of being returned to the surface.In accordance with an embodiment of the present disclosure, the AFOservice is initiated by the AFO specialist at step 1102 and monitors theoperations until a lost returns condition is detected at step 1104. Forinstance, a drop in pit volume may be an indication of a lost returnscondition. The AFO specialist may also verify the existence of a lostreturns condition with the rig. Next, at step 1106, the AFO specialistmay characterize the lost returns condition. Specifically, the AFOspecialist may analyze the pressure readings from the wellbore and lookfor spikes in pressure and/or the ECD. Next, at step 1108 the AFOspecialist may report its findings, analysis, and conclusions to theappropriate personnel. In certain embodiments, once in step 1108 the AFOspecialist identifies a lost returns condition or once the lost returnscondition is characterized in step 1106, the process may be directed tothe intervention workflow of FIG. 3 and an appropriate interventionsignal may be documented. The process then returns to step 1104 wherethe AFO specialist continues to monitor the subterranean operations todetect another potential lost returns condition.

Similarly, the AFO services may be used to monitor other operatingconditions of significance such as, for example, a plugged bit nozzle,bit/Bottom Hole Assembly (“BHA”) balling, and/or Barite sag. A drill bitnozzle may be plugged by materials flowing through the drillstring. Thisplugging may cause a sharp increase in SPP with a minimal (if any)increase in the PWD. Typically when a bit nozzle is plugged, thedrillstring may be pulled out to change out the jet nozzle. A bit/BHAballing condition refers to instances where materials from the formationstick to the drill bit or other components of the BHA and adverselyimpact the ability to drill the wellbore. This is a particularly commonproblem when operating in highly reactive shale. This condition istypically characterized by a reduction in the ROP. Finally, Barite sagrefers to instances when the suspension properties of the drilling mudare insufficient to hold Barite in the mud and the Barite sags. Thisproblem is of particular importance in high angle wellbores. Thiscondition may be detected, for example, when PWD EMW is lower thanprevious EMW (at pumps-off) or when PWD ECDs show higher than normalseparation from EMWs at pumps-on, tapering to a nominal ECD aftercirculation is established. The AFO specialist may handle a Barite sagcondition by increasing the mud's gel strength.

In accordance with an embodiment of the present disclosure, the AFOspecialist may utilize the intervention workflow method of FIG. 3 and anappropriate intervention signal may be documented in response to aplugged bit nozzle, bit/BHA balling and/or Barite sag.

Accordingly, as would be appreciated by those of ordinary skill in theart, with the benefit of this disclosure, data available from the IDE200 may improve drilling and fluid performance. As a result, operationaldecisions may be made quickly and may be based on current, real-timedata. Additionally, utilizing the IDE 200 will help eliminate or reducethe number of personnel needed at dangerous work locations and help anoperator prioritize which locations require more attention and personnelthan others. Moreover, in the case of land-based operations, the use ofthe IDE 200 may provide around the clock access to drilling parametersand drilling fluid properties which may empower a mud engineer to makebetter decisions to construct a wellbore with little intervention.

As would be appreciated by those of ordinary skill in the art, with thebenefit of this disclosure, one or more information handling systems maybe used to implement the methods disclosed herein. In certainembodiments, the different information handling systems may becommunicatively coupled through a wired or wireless system to facilitatedata transmission between the different subsystems. Moreover, eachinformation handling system may include a computer readable media tostore data generated by the subsystem as well as preset job performancerequirements and standards.

Therefore, the present invention is well-adapted to carry out theobjects and attain the ends and advantages mentioned as well as thosewhich are inherent therein. While the invention has been depicted anddescribed by reference to exemplary embodiments of the invention, such areference does not imply a limitation on the invention, and no suchlimitation is to be inferred. The invention is capable of considerablemodification, alteration, and equivalents in form and function, as willoccur to those ordinarily skilled in the pertinent arts and having thebenefit of this disclosure. The depicted and described embodiments ofthe invention are exemplary only, and are not exhaustive of the scope ofthe invention. Consequently, the invention is intended to be limitedonly by the spirit and scope of the appended claims, giving fullcognizance to equivalents in all respects. The terms in the claims havetheir plain, ordinary meaning unless otherwise explicitly and clearlydefined by the patentee.

What is claimed is:
 1. An integrated digital ecosystem comprising: anapplied fluid optimization specialist; one or more sensorscommunicatively coupled to the applied fluid optimization specialist;wherein the applied fluid optimization specialist receives data relatingto performance of subterranean operations from the one or more sensors;wherein the applied fluid optimization specialist interprets the datareceived from the one or more sensors; and wherein the applied fluidoptimization specialist regulates the performance of subterraneanoperations based on the interpretation of the data received.
 2. Thesystem of claim 1, wherein the data relating to performance ofsubterranean operations is selected from a group consisting of holedepth, bit depth, block position, hookload, True Vertical Depth,time/date activity, temperature, fluid flow rates into systemcomponents, fluid flow rates out of system components, fluid density,Riser flow in, stand pipe pressure, rotary RPM, torque, choke pressure,bottom hole temperature, rate of penetration, running speed, PressureWhile Drilling, Equivalent Mud Weight, pit volumes, pit volume change,and a combination thereof.
 3. The system of claim 1, further comprisingan applied fluid optimization Modeling and Planner communicativelycoupled to the applied fluid optimization specialist, wherein theapplied fluid optimization Modeling and Planner develops an executionplan prior to performance of subterranean operations.
 4. The system ofclaim 1, wherein data relating to performance of subterranean operationsis data relating to an inventory control system, and wherein the appliedfluid optimization specialist manages inventory using the data relatingto the inventory control system.
 5. The system of claim 1, wherein datarelating to performance of subterranean operations is data relating todrilling cuttings' characteristics, and wherein the applied fluidoptimization specialist regulates drilling operations using the datarelating to drilling cuttings' characteristics.
 6. The system of claim1, wherein data relating to performance of subterranean operations isdata relating to drilling operations and is selected from a groupconsisting of density, viscosity, Particle Size Distribution (“PSD”),oil/water ratio, electrical stability, percentage of solid content,Chloride concentration, Cation concentration, and pH.
 7. A method ofoptimizing performance of subterranean operations comprising: monitoringperformance of a subterranean operation; determining whether thesubterranean operation is being performed at an optimal level;identifying one or more causes for the subterranean operation not beingperformed at an optimal level; and generating an intervention if thesubterranean operation is not being performed at an optimal level,wherein level of intervention depends on the one or more causes for thesubterranean operation not being performed at an optimal level.
 8. Themethod of claim 7, wherein the level of intervention is selected from agroup consisting of a low level intervention, a medium levelintervention, and a high level intervention.
 9. The method of claim 7,wherein determining whether the subterranean operation is beingperformed at an optimal level comprises comparing simulated rig datawith actual rig data.
 10. The method of claim 7, further comprisingcommunicating the intervention to a Point of Contact, wherein the Pointof Contact handles the intervention.
 11. The method of claim 7, whereinthe subterranean operation is selected from a group consisting of adrilling operation and a hole cleaning operation.
 12. The method ofclaim 11, wherein the subterranean operation is the drilling operation,wherein determining whether the subterranean operation is beingperformed at an optimal level comprises comparing one or more simulateddrilling parameters with actual drilling parameters; and wherein thedrilling parameters are selected from a group consisting of downholepressure, mud weight, drillahead hydraulics, flow rates, standpipepressure, unit of gas, rate of penetration, torque and a combinationthereof.
 13. The method of claim 11, wherein the subterranean operationis the hole cleaning operation; wherein the hole cleaning operation isperformed by a rig; and wherein determining whether the subterraneanoperation is being performed at an optimal level comprises determiningwhether the rig is sliding.
 14. The method of claim 7, whereindetermining whether the subterranean operation is being performed at anoptimal level comprises determining whether there is at least one of anexcessive surge pressure, an excessive swab pressure, influx, Pack-Off,wellbore breathing, hole enlargement, lost returns, and a combinationthereof.
 15. A method of optimizing performance of a subterraneanoperation comprising: providing one or more sensors; wherein the one ormore sensors gather data relating to performance of the subterraneanoperation; monitoring data gathered by the one or more sensors toidentify one or more operational conditions; identifying need for anintervention based on the one or more identified operational conditions;determining an intervention level based on the gathered data; generatingan intervention corresponding to the determined intervention level; andresponding to the intervention based on the intervention level.
 16. Themethod of claim 15, wherein the one or more operational conditions areselected from a group consisting of excessive Surge pressure, excessiveSwab pressure, influx, Pack-Off, wellbore breathing, hole enlargement,and lost returns.
 17. The method of claim 15, wherein the subterraneanoperation is a drilling operation.
 18. The method of claim 15, whereinmonitoring data gathered by the one or more sensors to identify one ormore operational conditions comprises comparing actual data withsimulated data to identify the one or more operational conditions. 19.The method of claim 15, wherein the intervention level is selected froma group consisting of a low level intervention, a medium levelintervention, and a high level intervention.
 20. The method of claim 19,wherein responding to the intervention based on the intervention levelcomprises: probing the system to continue to monitor the identifiedoperational condition if a low level intervention is generated; at leastone of compiling a list of mitigation options to resolve the conditionand notifying an operator about the condition if a medium levelintervention is generated; and at least one of issuing a notification ofa significant adverse event, compiling a list of mitigation options toresolve the condition and notifying the operator about the condition ifa high level intervention is generated.